System and method for offshore (topside or subsea) and onshore water reinjection for secondary recovery

ABSTRACT

A system includes a fluid injection system. The fluid injection system includes a rotary isobaric pressure exchanger (IPX) configured to receive a first fluid, to receive a second fluid extracted from a source well, to utilize the second fluid to pressurize the first fluid for injection into an injection well, and to inject the pressurized first fluid into the injection well.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a continuation of U.S. patent application Ser. No.15/075,554, entitled “SYSTEM AND METHOD FOR OFFSHORE (TOPSIDE OR SUBSEA)AND ONSHORE WATER REINJECTION FOR SECONDARY RECOVERY”, filed Mar. 21,2016, which is herein incorporated by reference in its entirety.

BACKGROUND

This section is intended to introduce the reader to various aspects ofart that may be related to various aspects of the present invention,which are described and/or claimed below. This discussion is believed tobe helpful in providing the reader with background information tofacilitate a better understanding of the various aspects of the presentinvention. Accordingly, it should be understood that these statementsare to be read in this light, and not as admissions of prior art.

The subject matter disclosed herein relates to fluid handling, and, moreparticularly, to systems and methods for utilizing an isobaric pressureexchanger (IPX) in pressurizing water for injection in secondaryrecovery of hydrocarbons from reservoirs or for waste water disposal.

A variety of fluids may be used in the production or recovery ofhydrocarbons (e.g., oil and gas) from the earth. For example, during oiland gas production, produced water (i.e., water separated from a fluidincluding hydrocarbons) may be utilized in water injection to maintainpressure in a well or raise pressure in wells that do not producehydrocarbons under natural pressure. Typically, heavy water injectionpumps and associated power generation equipment are utilized to injectthe water (e.g., produced water) at a high pressure and a high flow rateinto an injection well (e.g., enhanced recovery well, disposal well,etc.). Similar equipment and methods may also be used for waste waterdisposal. This equipment has a large footprint and requires significantpower. On off-shore oil platforms, space, weight capacity, and powerresources are limited. In addition, water injection pumps areunreliable, costly, and difficult to service due to their size andcomplexities.

BRIEF DESCRIPTION OF THE DRAWINGS

Various features, aspects, and advantages of the present invention willbecome better understood when the following detailed description is readwith reference to the accompanying figures in which like charactersrepresent like parts throughout the figures, wherein:

FIG. 1 is an exploded perspective view of an embodiment of a rotaryisobaric pressure exchanger (IPX);

FIG. 2 is an exploded perspective view of an embodiment of a rotary IPXin a first operating position;

FIG. 3 is an exploded perspective view of an embodiment of a rotary IPXin a second operating position;

FIG. 4 is an exploded perspective view of an embodiment of a rotary IPXin a third operating position;

FIG. 5 is an exploded perspective view of an embodiment of a rotary IPXin a fourth operating position;

FIG. 6 is a schematic diagram of an embodiment of a fluid injectionsystem (e.g., with a separator) having a rotary IPX;

FIG. 7 is a schematic diagram of an embodiment of a fluid injectionsystem (e.g., without a separator) having a rotary IPX;

FIG. 8 is a schematic diagram of an embodiment of a fluid injectionsystem having a rotary IPX utilized offshore and located subsea;

FIG. 9 is a flowchart of an embodiment of a method for pressurizing afluid for injection or reinjection into a well;

FIG. 10 is a flowchart of an embodiment of a method for pressurizingproduced water for injection or reinjection into a well;

FIG. 11 is a schematic diagram of an embodiment of a fluidtransportation system having a rotary IPX utilized offshore and locatedsubsea (e.g., for moving oil above sea);

FIG. 12 is a schematic diagram of an embodiment of a fluidtransportation system having a rotary IPX utilized offshore and locatedsubsea (e.g., for transporting oil to shore);

FIG. 13 is a schematic diagram of an embodiment of a fluidtransportation system having a rotary IPX utilized offshore and locatedsubsea (e.g., for disposal of produced water);

FIG. 14 is a flowchart of an embodiment of a method for pressurizing oilfor moving above sea or transporting onshore; and

FIG. 15 is a flowchart of an embodiment of a method for pressurizingproduced water for disposal.

DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS

One or more specific embodiments of the present invention will bedescribed below. These described embodiments are only exemplary of thepresent invention. Additionally, in an effort to provide a concisedescription of these exemplary embodiments, all features of an actualimplementation may not be described in the specification. It should beappreciated that in the development of any such actual implementation,as in any engineering or design project, numerousimplementation-specific decisions must be made to achieve thedevelopers' specific goals, such as compliance with system-related andbusiness-related constraints, which may vary from one implementation toanother. Moreover, it should be appreciated that such a developmenteffort might be complex and time consuming, but would nevertheless be aroutine undertaking of design, fabrication, and manufacture for those ofordinary skill having the benefit of this disclosure.

When introducing elements of various embodiments of the presentinvention, the articles “a,” “an,” “the,” and “said” are intended tomean that there are one or more of the elements. The terms “comprising,”“including,” and “having” are intended to be inclusive and mean thatthere may be additional elements other than the listed elements.

As discussed in detail below, a fluid injection system (e.g. waterinjection system) includes a hydraulic energy transfer system thattransfers work and/or pressure between first and second fluids. In someembodiments, the hydraulic energy transfer system may be a rotatingisobaric pressure exchanger (IPX) that transfers pressure between a highpressure first fluid (e.g., high pressure multi-phase fluid containinghydrocarbon fluid such as oil or gas flowing from a producing well) anda low pressure second fluid (e.g., single phase fluid such as producedwater separated from hydrocarbons, treated water, sea water, etc.).Pressurizing the produced water for injection or reinjection into a lowpressure well (e.g., with a low recovery factor) enables stimulation ofthe well to increase the recovery factor. The equipment associated withthe fluid injection system including the IPX may also be utilized withdisposal wells onshore and offshore. The equipment associated with thefluid injection system including the IPX may be utilized in offshore oronshore hydrocarbon production operations. In offshore hydrocarbonproduction operations, some or all of the fluid injection systemequipment including the IPX may be disposed topside (i.e., on theplatform) and/or under water (i.e., subsea). The utilization of the IPXin the fluid injection system eliminates or reduces the need for highpressure, high flow rate pumps. In addition, the utilization of the IPXeliminates or reduces the need for power (e.g., electricity) utilized torun the pumps. The IPX would require little or no electrical power.Further, the utilization of the IPX reduces the footprint of the pumpand associated power generation equipment, especially on offshoreplatforms when the pump and/or other components of the fluid injectionsystem are moved under water (e.g., on the seafloor).

Yet further, the utilization of the IPX may eliminate or reduce the needfor a valve system (e.g., choke valve system) to reduce the pressure ofhydrocarbons (e.g., oil or gas) flowing from a producing well. Evenfurther, the replacement of the water injection pump with the IPX mayincrease recovery rates from wells. Still further, the utilization ofthe IPX is a simple solution. The IPX is compact, easy to maintain, andcan easily be deployed with redundancy.

The IPX may include one or more chambers (e.g., 1 to 100) to facilitatepressure transfer and equalization of pressures between volumes of firstand second fluids. In some embodiments, the pressures of the volumes offirst and second fluids may not completely equalize. Thus, in certainembodiments, the IPX may operate isobarically, or the IPX may operatesubstantially isobarically (e.g., wherein the pressures equalize withinapproximately +/−1, 2, 3, 4, 5, 6, 7, 8, 9, or 10 percent of eachother). In certain embodiments, a first pressure of a first fluid (e.g.,fluid including water and high pressure hydrocarbons such as oil or gasextracted from a producing well) may be greater than a second pressureof a second fluid (e.g., produced water separated from hydrocarbons,treated water, sea water, etc.). For example, the first pressure may bebetween approximately 5,000 kPa to 25,000 kPa, 20,000 kPa to 50,000 kPa,40,000 kPa to 75,000 kPa, 75,000 kPa to 100,000 kPa or greater than thesecond pressure. Thus, the IPX may be used to transfer pressure from afirst fluid (e.g., fluid including water and high pressure hydrocarbonssuch as oil or gas extracted from a producing well) at a higher pressureto a second fluid (e.g., produced water separated from hydrocarbons,treated water, sea water, etc.) at a lower pressure.

FIG. 1 is an exploded view of an embodiment of a rotary IPX 20 that maybe utilized in a fluid injection system, as described in detail below.As used herein, the isobaric pressure exchanger (IPX) may be generallydefined as a device that transfers fluid pressure between ahigh-pressure inlet stream and a low-pressure inlet stream atefficiencies in excess of approximately 50%, 60%, 70%, or 80% withoututilizing centrifugal technology. In this context, high pressure refersto pressures greater than the low pressure. The low-pressure inletstream of the IPX may be pressurized and exit the IPX at high pressure(e.g., at a pressure greater than that of the low-pressure inletstream), and the high-pressure inlet stream may be depressurized andexit the IPX at low pressure (e.g., at a pressure less than that of thehigh-pressure inlet stream). Additionally, the IPX may operate with thehigh-pressure fluid directly applying a force to pressurize thelow-pressure fluid, with or without a fluid separator between thefluids. Examples of fluid separators that may be used with the IPXinclude, but are not limited to, pistons, bladders, diaphragms and thelike. In certain embodiments, isobaric pressure exchangers may be rotarydevices. Rotary isobaric pressure exchangers (IPXs) 20, such as thosemanufactured by Energy Recovery, Inc. of San Leandro, Calif., may nothave any separate valves, since the effective valving action isaccomplished internal to the device via the relative motion of a rotorwith respect to end covers, as described in detail below with respect toFIGS. 1-5. Rotary IPXs may be designed to operate with internal pistonsto isolate fluids and transfer pressure with little mixing of the inletfluid streams. Reciprocating IPXs may include a piston moving back andforth in a cylinder for transferring pressure between the fluid streams.Any IPX or plurality of IPXs may be used in the disclosed embodiments,such as, but not limited to, rotary IPXs, reciprocating IPXs, or anycombination thereof. While the discussion with respect to certainembodiments for measuring the speed of the rotor may refer to rotaryIPXs, it is understood that any IPX or plurality of IPXs may besubstituted for the rotary IPX in any of the disclosed embodiments.

In the illustrated embodiment of FIG. 1, the rotary IPX 20 may include agenerally cylindrical body portion 40 that includes a housing 42 and arotor 44. The rotary IPX 20 may also include two end structures 46 and48 that include manifolds 50 and 52, respectively. Manifold 50 includesinlet and outlet ports 54 and 56 and manifold 52 includes inlet andoutlet ports 60 and 58. For example, inlet port 54 may receive ahigh-pressure first fluid and the outlet port 56 may be used to route alow-pressure first fluid away from the IPX 20. Similarly, inlet port 60may receive a low-pressure second fluid and the outlet port 58 may beused to route a high-pressure second fluid away from the IPX 20. The endstructures 46 and 48 include generally flat end plates 62 and 64,respectively, disposed within the manifolds 50 and 52, respectively, andadapted for liquid sealing contact with the rotor 44. The rotor 44 maybe cylindrical and disposed in the housing 42, and is arranged forrotation about a longitudinal axis 66 of the rotor 44.

The rotor 44 may have a plurality of channels 68 extending substantiallylongitudinally through the rotor 44 with openings 70 and 72 at each endarranged symmetrically about the longitudinal axis 66. The openings 70and 72 of the rotor 44 are arranged for hydraulic communication with theend plates 62 and 64, and inlet and outlet apertures 74 and 76, and 78and 80, in such a manner that during rotation they alternatelyhydraulically expose liquid at high pressure and liquid at low pressureto the respective manifolds 50 and 52. The inlet and outlet ports 54,56, 58, and 60, of the manifolds 50 and 52 form at least one pair ofports for high-pressure liquid in one end element 46 or 48, and at leastone pair of ports for low-pressure liquid in the opposite end element,48 or 46. The end plates 62 and 64, and inlet and outlet apertures 74and 76, and 78 and 80 are designed with perpendicular flow crosssections in the form of arcs or segments of a circle.

With respect to the IPX 20, the plant operator has control over theextent of mixing between the first and second fluids, which may be usedto improve the operability of the fluid handling system. For example,varying the proportions of the first and second fluids entering the IPX20 allows the plant operator to control the amount of fluid mixingwithin the fluid handling system. Three characteristics of the IPX 20that affect mixing are: the aspect ratio of the rotor channels 68, theshort duration of exposure between the first and second fluids, and thecreation of a liquid barrier (e.g., an interface) between the first andsecond fluids within the rotor channels 68. First, the rotor channels 68are generally long and narrow, which stabilizes the flow within the IPX20. In addition, the first and second fluids may move through thechannels 68 in a plug flow regime with very little axial mixing. Second,in certain embodiments, at a rotor speed of approximately 1200 RPM, thetime of contact between the first and second fluids may be less thanapproximately 0.15 seconds, 0.10 seconds, or 0.05 seconds, which againlimits mixing of the streams 18 and 30. Third, a small portion of therotor channel 68 is used for the exchange of pressure between the firstand second fluids. Therefore, a volume of fluid remains in the channel68 as a barrier between the first and second fluids. All thesemechanisms may limit mixing within the IPX 20.

In addition, because the IPX 20 is configured to be exposed to the firstand second fluids, certain components of the IPX 20 may be made frommaterials compatible with the components of the first and second fluids.In addition, certain components of the IPX 20 may be configured to bephysically compatible with other components of the fluid handlingsystem. For example, the ports 54, 56, 58, and 60 may comprise flangedconnectors to be compatible with other flanged connectors present in thepiping of the fluid handling system. In other embodiments, the ports 54,56, 58, and 60 may comprise threaded or other types of connectors.

FIGS. 2-5 are exploded views of an embodiment of the rotary IPX 20illustrating the sequence of positions of a single channel 68 in therotor 44 as the channel 68 rotates through a complete cycle, and areuseful to an understanding of the rotary IPX 20. It is noted that FIGS.2-5 are simplifications of the rotary IPX 20 showing one channel 68 andthe channel 68 is shown as having a circular cross-sectional shape. Inother embodiments, the rotary IPX 20 may include a plurality of channels68 (e.g., 2 to 100) with different cross-sectional shapes. Thus, FIGS.2-5 are simplifications for purposes of illustration, and otherembodiments of the rotary IPX 20 may have configurations different fromthat shown in FIGS. 2-5. As described in detail below, the rotary IPX 20facilitates a hydraulic exchange of pressure between two liquids byputting them in momentary contact within a rotating chamber. In certainembodiments, this exchange happens at a high speed that results in veryhigh efficiency with very little mixing of the liquids.

In FIG. 2, the channel opening 70 is in hydraulic communication withaperture 76 in endplate 62 and therefore with the manifold 50 at a firstrotational position of the rotor 44 and opposite channel opening 72 isin hydraulic communication with the aperture 80 in endplate 64, andthus, in hydraulic communication with manifold 52. As discussed below,the rotor 44 rotates in the clockwise direction indicated by arrow 90.As shown in FIG. 2, low-pressure second fluid 92 passes through endplate 64 and enters the channel 68, where it pushes first fluid 94 outof the channel 68 and through end plate 62, thus exiting the rotary IPX20. The first and second fluids 92 and 94 contact one another at aninterface 96 where minimal mixing of the liquids occurs because of theshort duration of contact. The interface 96 is a direct contactinterface because the second fluid 92 directly contacts the first fluid94.

In FIG. 3, the channel 68 has rotated clockwise through an arc ofapproximately 90 degrees, and outlet 72 is now blocked off betweenapertures 78 and 80 of end plate 64, and outlet 70 of the channel 68 islocated between the apertures 74 and 76 of end plate 62 and, thus,blocked off from hydraulic communication with the manifold 50 of endstructure 46. Thus, the low-pressure second fluid 92 is contained withinthe channel 68.

In FIG. 4, the channel 68 has rotated through approximately 180 degreesof arc from the position shown in FIG. 2. Opening 72 is in hydrauliccommunication with aperture 78 in end plate 64 and in hydrauliccommunication with manifold 52, and the opening 70 of the channel 68 isin hydraulic communication with aperture 74 of end plate 62 and withmanifold 50 of end structure 46. The liquid in channel 68, which was atthe pressure of manifold 52 of end structure 48, transfers this pressureto end structure 46 through outlet 70 and aperture 74, and comes to thepressure of manifold 50 of end structure 46. Thus, high-pressure firstfluid 94 pressurizes and displaces the second fluid 92.

In FIG. 5, the channel 68 has rotated through approximately 270 degreesof arc from the position shown in FIG. 2, and the openings 70 and 72 ofchannel 68 are between apertures 74 and 76 of end plate 62, and betweenapertures 78 and 80 of end plate 64. Thus, the high-pressure first fluid94 is contained within the channel 68. When the channel 68 rotatesthrough approximately 360 degrees of arc from the position shown in FIG.3, the second fluid 92 displaces the first fluid 94, restarting thecycle.

FIG. 6 is a schematic diagram of an embodiment of a fluid injectionsystem 100 (e.g., with a separator 102) having a rotary IPX 104. Asnoted above, the fluid injection system 100 may be utilized in offshoreor onshore hydrocarbon production operations. In offshore hydrocarbonproduction operations, some or all of the fluid injection systemequipment including the IPX 104 may be disposed topside (i.e., on theplatform) and/or under water (i.e., subsea). In other words all of thefluid injection system equipment may be located topside, all of thefluid injection system equipment may be located under water, or some ofthe fluid injection system equipment may be located topside and the restof the equipment located under water. The fluid injection system 100includes the IPX 104 as described above. The fluid injection system 100also includes a separator 102 (e.g., pressure vessel) to separatevarious components (e.g., oil, gas, solids such rocks or other sediment,produced water, or other components) from the fluid 106 (e.g., highpressure fluid) extracted from a source well 108 (e.g., producing well).The fluid injection system 100 further includes one or more flow controldevices 110 (e.g., pumps, valves, eductors, etc.) to control the flow offluids within the fluid injection system 100. For example, as depictedin FIG. 6, a flow control device 112 is disposed along a fluid flow path114 (e.g., low pressure produced water flow path) between the separator102 and the IPX 104. Also, a flow control device 116 is disposed along afluid flow path 118 (high pressure produced water flow path) between theIPX 104 and an injection well 120 (e.g., enhanced recovery well,disposal well, etc.). In certain embodiments, the fluid injection system100 includes a treatment system 122 to treat the produced water (e.g.,low pressure produced water along the fluid flow path 114. For example,the treatment system 122 may provide or inject one or more chemicalswith low surface tension into the low pressure produced water upstreamof a low pressure inlet 124 of the IPX 104 to lower the surface tensionof the low pressure produced water.

The fluid injection system 100 functions by receiving a high pressurefluid 106 (e.g., including hydrocarbons such as oil and/or gas)extracted from the source well 108. The high pressure fluid 106 flowsinto a high pressure inlet 126 of the IPX 104. Low pressure producedwater or treated produced water 128 flows from the separator 102 (or atank that stores the generated produced water) to the low pressure inlet124 of the IPX 104. The flow control device 112 may regulate the flow ofthe low pressure produced water or treated produced water 128 to the IPX104. In the IPX 104, pressure is transferred from the high pressurefluid 106 to the low pressure produced water 128 resulting in a lowpressure fluid 130 for the fluid 106 extracted from the source well 108and a high pressure produced water 132. The high pressure produced water132, after exiting a high pressure outlet 134 of the IPX 104, isutilized by the fluid injection system 100 for injection or reinjectioninto the injection well 120, e.g., in recovery wells, to enhancerecovery of hydrocarbons from a hydrocarbon reservoir. The flow controldevice 116 may regulate the flow of the high pressure produced water 132for injection into the injection wall 120. The low pressure fluid 130(e.g., including hydrocarbons), after exiting a low pressure outlet 136of the IPX 104, is provided to the separator 102 for separation intovarious components (e.g., oil, gas, produced water, etc.). The producedwater 128 generated by the separator 102 may be stored in a tank orutilized immediately in injection operations.

FIG. 7 is a schematic diagram of an embodiment of fluid injection system100 (e.g., without a separator 102) having the rotary IPX 104. As notedabove, the fluid injection system 100 may be utilized in offshore oronshore hydrocarbon production operations. In offshore hydrocarbonproduction operations, some or all of the fluid injection systemequipment including the IPX 104 may be disposed topside (i.e., on theplatform) and/or under water (i.e., subsea). In other words all of thefluid injection system equipment may be located topside, all of thefluid injection system equipment may be located under water, or some ofthe fluid injection system equipment may be located topside and the restof the equipment located under water. The fluid injection system 100includes the IPX 104 as described above. The fluid injection system 100further includes one or more flow control devices 110 (e.g., pumps,valves, eductors, etc.) to control the flow of fluids within the fluidinjection system 100. For example, as depicted in FIG. 7, a flow controldevice 112 is disposed along the fluid flow path 114 (e.g., low pressurefluid flow path) between a source 138 (e.g., tank) of low pressure fluid128 such as treated water (e.g., produced water or water source treatedas described above in FIG. 6) or seawater and the IPX 104. Also, a flowcontrol device 116 is disposed along the fluid flow path 118 (highpressure produced water flow path) between the IPX 104 and an injectionwell 120 (e.g., enhanced recovery well, disposal well, etc.). In certainembodiments, the fluid injection system 100 includes a treatment system(e.g., disposed along path 114 upstream or downstream of the source 138)to treat the low pressure water 128 as described above.

The fluid injection system 100 functions by receiving a high pressurefluid 106 (e.g., including hydrocarbons such as oil and/or gas)extracted from the source well 108. The high pressure fluid 106 flowsinto the high pressure inlet 126 of the IPX 104. Low pressure treatedwater or seawater 128 flows from the source 138 (e.g., tank) to the lowpressure inlet 124 of the IPX 104. The flow control device 112 mayregulate the flow of the low pressure treated water or seawater 128 tothe IPX 104. In the IPX 104, pressure is transferred from the highpressure fluid 106 to the low pressure treated water or seawater 128resulting in a low pressure fluid 130 for the fluid extracted from thesource well 108 and a high pressure treated water or seawater 132. Thehigh pressure treated water or seawater 132, after exiting the highpressure outlet 134 of the IPX 104, is utilized by the fluid injectionsystem 100 for injection or reinjection into the injection well 120,e.g., in recovery wells, to enhance recovery of hydrocarbons from ahydrocarbon reservoir. The flow control device 116 may regulate the flowof the high pressure treated water or seawater 132 for injection intothe injection wall 120. The low pressure fluid 130 (e.g., includinghydrocarbons), after exiting the low pressure outlet 136 of the IPX 104,is provided to further production equipment (e.g., a separator forseparation into various components (e.g., oil, gas, solids, producedwater, etc.)).

FIG. 8 is a schematic diagram of an embodiment of a fluid injectionsystem 100 having a rotary IPX 104 utilized offshore (e.g., on an oilplatform 140). In general, the fluid injection system 100 in FIG. 8operates as described in FIG. 6. As depicted in FIG. 8, the separator102 is located topside on the oil platform, while the IPX 104 is locatedunder water (e.g., on the sea floor). In certain embodiments of thefluid injection system 100, the separator 102 may be located under wateralso. In other embodiments, the IPX 104 may be located topside on theoil platform 140. The location of the components of the fluid injectionsystem 100 (in particular, the IPX 104) depends on the conditions of thereservoir and other factors.

FIG. 9 is a flowchart of an embodiment of a method 142 for pressurizinga fluid for injection or reinjection into a well 120 (e.g., injectionwell). The method 142 includes extracting a high pressure fluid (e.g.,including hydrocarbons such as oil and/or gas) from a source well 108(e.g., producing well) (block 144). The method 142 also includesutilizing the IPX 104 to transfer pressure from the high pressure fluidto a low pressure fluid (e.g., sea water, treated water, produced water,treated produced water, etc.) for use in injection (or reinjection)(block 146). The low pressure fluid enters the IPX 104 via a lowpressure inlet 124. In certain embodiments, the method 142 includestreating the low pressure fluid as described above upstream of the lowpressure inlet 124 of the IPX 104 (block 148). The method 142 includesinjecting (or reinjecting) the pressurized fluid (e.g., sea water,treated water, produced water, treated produced water, etc.), after itexits the IPX 104 via a high pressure outlet 134, into an injection well120 (e.g., enhanced recovery well, disposal well, etc.) (block 150). Thefluid (e.g., including hydrocarbons) utilized to pressurize the lowpressure fluid (e.g., sea water, treated water, produced water, treatedproduced water, etc.) exits the IPX 104 at a lower pressure via a lowpressure outlet 136.

FIG. 10 is a flowchart of an embodiment of a method 152 for pressurizingproduced water for injection or reinjection into a well 120. The method152 includes extracting a high pressure fluid (e.g., includinghydrocarbons such as oil and/or gas) from a source well 108 (e.g.,producing well) (block 154). The method 152 also includes utilizing theIPX 104 to transfer pressure from the high pressure fluid to the lowpressure produced water or treated produced water (block 156). The lowpressure produced water enters the IPX 104 via a low pressure inlet 124.In certain embodiments, the method 152 includes treating the lowpressure fluid as described above upstream of the low pressure inlet ofthe IPX 104 (block 162). The method 152 includes injecting (orreinjecting) the pressurized produced water, after it exits the IPX 104via a high pressure outlet 134, into an injection well 120 (e.g.,enhanced recovery well, disposal well, etc.) (block 158). The fluid(e.g., including hydrocarbons) utilized to pressurize the produced wateror treated produced water exits the IPX 104 at a lower pressure via alow pressure outlet 136. The method 152 includes utilizing a separator102 to separate the low pressure fluid (i.e., including thehydrocarbons) into a variety of components (e.g., oil, gas, rock,produced water, etc.) (block 160). The produced water separated from thelow pressure fluid may be utilized for injection or reinjection into thewell 120 upon pressurization within the IPX 104.

The IPX 104 and/or separator 102 may be utilized for applications(described in FIGS. 11-15) other than injection or reinjection. FIG. 11is a schematic diagram of an embodiment of a fluid transport system 160having a rotary IPX 104 utilized offshore (e.g., on an oil platform140). As depicted in FIG. 11, both the separator 102 and the IPX 104 arelocated under water (e.g., on the sea floor). In other embodiments, theIPX 104 and/or the separator 102 may be located topside on the oilplatform 140. The location of the components of the fluid transportsystem 160 (in particular, the IPX 104) depends on the conditions of thereservoir and other factors.

The fluid transport system 160 functions by receiving a high pressure,multi-phase fluid 106 (e.g., including water and hydrocarbons such asoil and/or gas) extracted from the source well 108. The high pressurefluid 106 flows into a high pressure inlet 126 of the IPX 104. A lowpressure, single phase fluid 162 such as oil flows from the separator102 (or a tank that stores the oil) to the low pressure inlet 124 of theIPX 104. In certain embodiments, a flow control device may regulate theflow of the oil 162 to the IPX 104. In the IPX 104, pressure istransferred from the high pressure fluid 106 to the low pressure oil 162resulting in a low pressure fluid 164 for the fluid 106 extracted fromthe source well 108 and a high pressure oil 166. The high pressure oil166, after exiting a high pressure outlet 134 of the IPX 104, isutilized by the fluid transport system 160 for lifting or transportingthe oil 166 above the sea surface to the oil platform 140 (e.g., to atank 168 or vessel). In certain embodiments, a flow control device mayregulate the flow of the high pressure oil 166 above the sea surface toits destination. The low pressure fluid 164 (e.g., includinghydrocarbons), after exiting a low pressure outlet 136 of the IPX 104,is provided to the separator 102 for separation into various components(e.g., oil, gas, produced water, etc.).

FIG. 12 is a schematic diagram of an embodiment of a fluid transportsystem 160 having a rotary IPX 104 utilized offshore (e.g., on an oilplatform 140). The fluid transport system 160 is as described in FIG. 11except the high pressure oil 166 is transported to an onshore storagefacility 170. In certain embodiments, the fluid transport system 160 ofFIGS. 11 and 12 may be utilized for pressurizing gas for moving ortransporting the gas.

FIG. 13 is a schematic diagram of an embodiment of a fluid transportsystem 160 having a rotary IPX 104 utilized offshore (e.g., on an oilplatform 140). As depicted in FIG. 11, both the separator 102 and theIPX 104 are located under water (e.g., on the sea floor). In otherembodiments, the IPX 104 and/or the separator 102 may be located topsideon the oil platform 140. The location of the components of the fluidtransport system 160 (in particular, the IPX 104) depends on theconditions of the reservoir and other factors. The fluid transportsystem 160 operates similar to the fluid injection system 100 of FIG. 8except the produced water 132 is not utilized for injection orreinjection but instead disposed of. Instead, as depicted in FIG. 13,the high pressure produced water 132 may be disposed of by dischargingit into the sea (as indicated by reference numeral 172), transporting itto a treatment facility 174 onshore, or transporting to a treatmentfacility 176 on the oil platform 140. The treatment facilities 174, 176treat the produced water 132 to remove contaminants.

FIG. 14 is a flowchart of an embodiment of a method 178 for pressurizingoil for moving above sea or transporting onshore. The method 178includes extracting a high pressure, multi-phase fluid (e.g., includingwater and hydrocarbons such as oil and/or gas) from a source well 108(e.g., producing well) (block 180). The method 178 also includesutilizing the IPX 104 to transfer pressure from the high pressure,multi-phase fluid to the low pressure oil (single phase fluid) (block182). The low pressure oil enters the IPX 104 via a low pressure inlet124. The method 178 includes moving the pressurized oil above sea levelor transporting it onshore (block 184) after it exits the IPX 104 via ahigh pressure outlet 134. The multi-phase fluid utilized to pressurizethe oil exits the IPX 104 at a lower pressure via a low pressure outlet136. The method 178 includes utilizing a separator 102 to separate thelow pressure fluid (i.e., including water and hydrocarbons) into avariety of components (e.g., oil, gas, rock, produced water, etc.)(block 186). The produced water separated from the low pressure fluidmay be utilized for injection or reinjection into the well 120 uponpressurization within the IPX 104.

FIG. 15 is a flowchart of an embodiment of a method 188 for pressurizingproduced water for disposal. The method 188 includes extracting a highpressure, multi-phase fluid (e.g., including water and hydrocarbons suchas oil and/or gas) from a source well 108 (e.g., producing well) (block190). The method 188 also includes utilizing the IPX 104 to transferpressure from the high pressure, multi-phase fluid to a low pressurefluid (e.g., produced water) for disposal (block 192). The low pressurefluid (e.g., produced water) enters the IPX 104 via a low pressure inlet124. The method 188 includes disposing of the pressurized fluid (e.g.,produced water) after it exits the IPX 104 via a high pressure outlet134 (block 194). The high pressure produced water may be discharged intothe sea or transported to a treatment facility to remove contaminants.The multi-phase fluid (e.g., including water and hydrocarbons) utilizedto pressurize the low pressure fluid (e.g., produced water) exits theIPX 104 at a lower pressure via a low pressure outlet 136.

While the invention may be susceptible to various modifications andalternative forms, specific embodiments have been shown by way ofexample in the drawings and have been described in detail herein.However, it should be understood that the invention is not intended tobe limited to the particular forms disclosed. Rather, the invention isto cover all modifications, equivalents, and alternatives falling withinthe spirit and scope of the invention as defined by the followingappended claims.

What is claimed is:
 1. A system, comprising: a fluid transportation system configured to transport a single phase fluid, comprising: a separator configured to separate a multi-phase fluid extracted from a source well into a plurality of components, wherein the plurality of components comprises at least the single phase fluid; a rotary isobaric pressure exchanger (IPX) configured to receive the single phase fluid, to receive the multi-phase fluid extracted from the source well, to utilize the multi-phase fluid to pressurize the single phase fluid to enable transport of the single phase fluid to a designated location.
 2. The system of claim 1, wherein the single phase fluid comprises oil.
 3. The system of claim 2, wherein designated location is located above a sea surface.
 4. The system of claim 3, wherein the designated location comprises an oil platform.
 5. The system of claim 3, wherein the designated location comprises a vessel.
 6. The system of claim 3, wherein the designated location is located onshore.
 7. The system of claim 1, wherein the single phase fluid comprises produced water.
 8. The system of claim 8, wherein the designated location is a treatment facility on a platform above the sea surface.
 9. The system of claim 8, wherein the designated location is a treatment facility located onshore.
 10. The system of claim 8, wherein the designated location is within the sea.
 11. The system of claim 1, wherein the single phase fluid is derived from the multi-phase fluid by the separator subsequent to the multi-phase fluid passing through the rotary IPX.
 12. The system of claim 1, wherein the separator is disposed on a platform above the sea surface.
 13. The system of claim 1, wherein the rotary IPX is disposed on a platform above the sea.
 14. The system of claim 1, wherein the rotary IPX is disposed below the sea surface.
 15. The system of claim 1, wherein the separator is disposed below the sea surface.
 16. A system, comprising: a fluid transportation system, comprising: a rotary isobaric pressure exchanger (IPX) configured to receive a single phase fluid derived from a multi-phase fluid extracted from a source well, to receive the multi-phase fluid extracted from the source well, to utilize the multi-phase fluid to pressurize the single phase fluid to enable transport of the single phase fluid to a designated location.
 17. The system of claim 16, wherein the single phase fluid comprises oil.
 18. The system of claim 17, wherein designated location is located above a sea surface.
 19. The system of claim 17, wherein the designated location is located onshore.
 20. The system of claim 16, wherein the single phase fluid comprises produced water.
 21. The system of claim 20, wherein the designated location is a treatment facility on a platform above the sea surface or a treatment facility located onshore.
 22. The system of claim 16, wherein the single phase fluid is derived from the multi-phase fluid by a separator subsequent to the multi-phase fluid passing through the rotary IPX.
 23. A method for utilizing a fluid transportation system in a hydrocarbon extraction operation, comprising: extracting a high pressure, multi-phase fluid from a source well; utilizing a rotary IPX to pressurize a single phase fluid using the high pressure, multi-phase fluid; and transporting a pressurized single phase fluid from the rotary IPX to a designated location.
 24. The method of claim 23, separating, via a separator, the single phase fluid from the high pressure, multi-phase fluid subsequent to the high pressure, multi-phase fluid being utilized to pressurize the single phase fluid. 